In Vitro Evaluation of the Impact of Nano Zinc Oxide on Stabilization of Shale FormationsHamidPourkhalilInstitute of Petroleum Engineering, Tehran University, Tehran, IranauthorAliNakhaeeInstitute of Petroleum Engineering, Tehran University, Tehran, IranauthoralirezanasiriUnit Drilling, Exploration and Production Center, Research Institute of Petroleum Industry, Tehran, IranauthorMajidValizadehUnit Drilling, Exploration and Production Center, Research Institute of Petroleum Industry, Tehran, Iranauthortextarticle2017perInstability of shale formations is one of the major challenges during a drilling operation. Shale swelling is a time-dependent process in which water gradually infiltrates the shale structure. Due to very low permeability of shales (10-6 - 10-12 D) and relatively large size of solid materials of drilling mud compared to shale pore throats (3-100 nm), filter cake is not capable of hindering this process. As a result, mud filtrate continuously seeps into shale, concurrently increasing pore pressure and reducing mechanical strength of the formation, where it may result in wellbore caving. One remedy to this hazard is the use of Nano-materials to block the entrance of mud filtrate into shale formations. Using nano-particle additives is one of the methods to reduce the entrance of mud filtrate into the shale formations. The present research investigates the application of Nano ZnO in controlling shale swelling. This nano particle benefits size adequacy as well as suitable interfacial properties in controlling mud filtration. The impact of adding nano ZnO to reduce water seepage into shale is investigated using PPT apparatus. This test shows the increase in pore pressure in the formation due to mud filtrate invasion, hence enabling us to study the effect of different additives on stability of shales. The results show that Nano ZnO particles reduces shale’s wettability effectively, and thereby reducing water penetration, due to their sizes and other chemo-physical properties; such as, specific surface area, electric charge. Using 0.25, 0.5 and 0.75 weight/volume percentage of Nano-ZnO mixture shows respectively %60 ,%87, and %96 reduction in pore pressure transmission compared to a sea water sample.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

2017414http://pr.ripi.ir/article_695_8dc8f240ec957818ff0d62971bc99954.pdfdx.doi.org/10.22078/pr.2017.695The Prediction of Semiclathrate Hydrate Dissociation Conditions by Artificial Neural Network Tools for the Systems of (Methane / Carbon Dioxide / Nitrogen) + TBAC + WaterAbolfazlMohammadiFaculty of Engineering, University of Bojnord, IranauthorZeinabArabasadiFaculty of Science, University of Bojnord, IranauthorAlirezaJahangiriFaculty of Engineering, Shahrekord University, IranauthorAli AsgharYarifardFaculty of Engineering, University of Bojnord, Iranauthortextarticle2017perSemiclathrate hydrates are new structure of gas hydrates that dramatically promote the gas hydrate dissociation conditions, but there are few thermodynamic models to predict the semiclathrate hydrate dissociation conditions. In this research, the multi-layer perceptron artificial neural network tools were employed to predict the semiclathrate hydrate dissociation conditions for the systems of methane + TBAC + water, carbon dioxide + TBAC + water, and nitrogen + TBAC + water. A wide range of experimental data which was reported in the literature was used to develop this algorithm. Mass fraction (0 - 0.3618) TBAC aqueous solution data were utilized to train the artificial neural network. %85 of literature data points were used to train and develop the network and 15% of literature data points were used to examine the developed artificial neural networks. The predicted data by the developed artificial neural network (for the systems of methane + TBAC + water, carbon dioxide + TBAC + water, and nitrogen + TBAC + water) showed an acceptable agreement with experimental data.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

20171525http://pr.ripi.ir/article_688_4fe7b75feb2566c8a199a21ed3a8565c.pdfdx.doi.org/10.22078/pr.2017.688Investigation of Nanoporous Graphene Effect on Enrichment Natural Gas by Hydrate ProcessesahmadghozatlooFaculty member of Research, Institute of Petroleum Industry, (RIPI), TehranauthorMojtabaShariaty-NiassarDepartment of Chemical Engineering, School of Engineering, University of Tehran, Iranauthortextarticle2017perIn this article, the structure of graphene nano-porous investigated by SEM image and Raman spectroscopy. Then the nano fluid of graphene nanostructures with 1% wt was used in gas hydrate formation process. SDS used as surfactant to enhancement of graphene stability in water. The nanofluid was in contact of natural gas under 1000 psig and °4C in cylindrical reactor and gas hydrate formed in the reactor by time. It was observed that the amount of gas storage increased by 14.6% while the induction time of the process was decreasing. The hydrate turns to unstable with increasing temperature of reactor and gas was released. The composition of natural gas in the top of reactor analyzed by GC and compared with initial natural gas. The results showed that light combination of natural gas; such as, methane increased from 92.7 to %96.15 and impurities; such as, carbon dioxide removed and undesirable compounds; such as, nitrogen and oxygen reduced. So, enrichment and purification of natural gas was performed without spending extra time and cost.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

20172635http://pr.ripi.ir/article_697_358f9034483af57adca4e88aa5dc3e07.pdfdx.doi.org/10.22078/pr.2017.697Geostatistical Wellbore Instability Risk Simulation Using Geomechanical Modeling Constraining Lithofacies Distribution of Nowrooz FieldSadjadKazem ShiroodiGeology Department, Faculty of Science, Ferdowsi University, Mashhad, IranauthorMohammadGhafooriGeology Department, Faculty of Science, Ferdowsi University, Mashhad, IranauthorGolam RezaLashkaripourGeology Department, Faculty of Science, Ferdowsi University, Mashhad, IranauthorNaserHafezi MoghadasGeology Department, Faculty of Science, Ferdowsi University, Mashhad, Iranauthortextarticle2017perPhisico-mechanical properties of rock vary because of complexity of geology and its heterogeneity and changing of litofacies and geometry of structure. An statistical analysis is the appropriate method to analyze the risk based on uncertainties among rock properties. The weakness of this method is summarized in two points: (1) spatial patterns and (2) relations of those data are discarded. In order to cope with the challenge, a geostatistical simulation which is considering lateral changes and geometry of structure give us a proper solution. According to scaterness of compressional and shear velocities of rock due to litofacies variation, modeling of shear velocity was done utilizing bivariate statistics conditioning to litofacies model which has been constructed using acoustic impedance and seismic porosity. Mechanical properties were then modeled based wave velocities and rock density. The risk analysis has been done based on well stability analysis using Mohr-Coulomb criteria. The study’s simulations were done on Kazdumi as a clastic dominant reservoir, and the study’s simulations were done on Darian-Gadvan as a carbonate dominant reservoir. The result shows high risk of instability in shale and argillaceous lithofacies and low risk sand and carbonate litofacies. It means that litofacies controls the instability risk.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

20173647http://pr.ripi.ir/article_701_533c58b23e8bddc03b191e7f951edfea.pdfdx.doi.org/10.22078/pr.2017.701CFD study of the effect of vapor directional valve on the sieve tray performanceTalebZareiDepartment of Mechanical Engineering, University of Horrmozgan, Bandar Abbas, IranauthorRahbarRahimiDepartment of chemical Engineering, Sistan and Baluchestan University, Zahedan, Iranauthortextarticle2017perIn this paper, A 3D model in the Eulerian- Eulerian framework for the prediction of the two phase tray hydrodynamic with ANSYS CFX software was used. CFD of the sieve tray was validated with experimental data. Results showed good agreement between an experimental simulation and CFD simulation. Then, to improve sieve tray performance and eliminate stagnant point on the tray, the different arrangement of the vapor directional valve was implemented. The best directional valve arrangement was 8 number valves on the sieve tray. The results show that the ratio of the vapor directional valve open area to the total hole area is an important parameter in the tray design. This dimensionless parameter for the 8 number arrangement is 14.31%. Therefore, this improved sieve tray with the optimum number directional valve can be used in the debottlenecking and future design of sieve trays.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

20176073http://pr.ripi.ir/article_700_19482fdd1a19685722bb51952cffd114.pdfdx.doi.org/10.22078/pr.2017.700numerical investigation of thermal conductivty enhancement in porous medium treated with high conductive nanoparticles.Mohammad RezaRokhforouzDepartment of Chemical and Petroleum Engineering, Sharif University of Technology, Tehran, IranauthorMalihehBarahoeiDepartment of Chemical Engineering, University of Isfahan, IranauthorShahabAyatollahiDepartment of Chemical and Petroleum Engineering, Sharif University of Technology, Tehran, Iranauthortextarticle2017perIt’s possible to couple the EOR and nanotechnology to utilize the efficiency of both methods. This study is conducted in two steps, (1) experimental and (2) simulation. In the first stage of experimental section, a stable and uniform water-based solution of nano-sized particles of copper oxide with different concentrations (0.01 to 0.05 M) were prepared and then injected into the core samples. Then using a homemade apparatus, thermal conductivity of cores at different cases include dry core, water saturated, nano saturated and dried after one week was measured. The experimental results showed %25 and 6% enhancement of thermal conductivity of nano saturated and water saturated core, respectively relative to the dry core thermal conductivity. In the simulation section, the modeling domain was constructed with realistic morphology to represent cores’ structure. Structural details of cores are obtained by image processing of two captured images from thin sections of cores. The experimental data have been used and validations have been performed by comparing temperature difference variation along to the core for different cases. The simulation approach has been performed by solving heat transfer equations with a commercial finite element package (COMSOL™). The Simulation results of two used models show that the thermal conductivity of nano saturated models have 14% and 8% enhancement, respectively. The obtained results are consistent with experimental data and simulate the improvement of ETC after nanofluid injection. The present study demonstrates that computational fluid dynamics can be a reliable approach to confirm empirical data.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

20177487http://pr.ripi.ir/article_698_28ee377a650ebbe8fb5a381b3566bcfd.pdfdx.doi.org/10.22078/pr.2017.698One-Pot Hydrothermal Synthesis of Nanostructured LaAPSO-34 Molecular Sieve and Sono-dispersion of Cr over it Used in Conversion of Ethane to Ethylene in the Presence of Carbon DioxideFarhadRahmaniChemical Engineering Faculty, Sahand University of Technology, Sahand New Town, TabrizauthorMohammadHaghighiChemical Engineering Faculty, Sahand University of Technology, Sahand New Town, Tabrizauthortextarticle2017perDehydrogenation of ethane to ethylene in the presence of CO2 has been carried out over chromium oxide catalysts sonochemically supported on parent SAPO-34 and nanostructured LaAPSO-34 molecular sieve with the aim of understanding the effects of support nature and La incorporation on the physicochemical properties and performance of catalyst. Like SAPO-34, nanostructured LaAPSO-34 with nominal Si/Al ratio of 0.3 in the gel was successfully synthesized via one-pot hydrothermal method as evidenced by XRD, FESEM, BET, EDX and FTIR techniques. Based on the characterization results, La incorporation into the framework of SAPO-34, not only complete crystallinity of SAPO-34, but increases in the surface area resulted in higher dispersion of Cr species and more uniform surface morphology. This reflects in higher content of redox Cr species stabilized in comparison with parent SAPO-34(0.3), which accounts for superior catalytic performance and stability of Cr/LaAPSO-34 (0.30) nanocatalyst. Moreover, more active sites which have been attributed to the higher amount of OH groups for La-doped SAPO-34 were proved by FTIR analysis. By employing SAPO-34 supports, a reasonable catalytic performance was observed. Doping SAPO-34(0.3) by lanthanum metal endows a most efficient support applicable for the selective oxidative dehydrogenation process. It was found that Cr/LaAPSO-34(0.3) effectively dehydrogenated ethane to ethylene in the presence of CO2 at °700C even after 5 hrs on-stream operation, giving 45% and 93% ethylene yield and selectivity, respectively. Less sensitivity to deactivation during the course of running the reaction evidently indicated the synergism effect of lanthanum existence and ultrasound irradiation on alleviating the catalyst deactivation in ethane dehydrogenation with CO2.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

201788103http://pr.ripi.ir/article_699_930f6d2b322d37d35de4eb95f24730d6.pdfdx.doi.org/10.22078/pr.2017.699Comparison of Reservoir properties and pore network characterization of limestone and dolomite units: A case study from Kangan and Dalan gas reservoirs at South Pars fieldPeymanBazvandGeology Department of NIOC Exploration Directorate, Tehran, IranauthorAliKadkhodaieEarth Science Department, Faculty of Natural Science, University of Tabriz, Iranauthortextarticle2017perSouth Pars gas field which is the host of largest gas reserves in the world is located on Iran- Qatar border line in Persian Gulf waters. Main reservoir rocks of this field are the Permo-Triassic Upper Dalan member and Kangan formation. Lithology of this succession is predominantly carbonate and composed of limestone and dolomite. Dolomitization is one of the most important diagenetic features. In addition to, dolomitization has mainly affected this succession and changed reservoir parameters and pore network characterizations. In this study, some reservoir properties and pore network parameters; such as, porosity, permeability, pore size and pore throat size of limestone and dolomite units have been evaluated and compared. The results show that Dolomite units, despite of lower porosity and smaller pores have higher permeability and subsequently better reservoir quality than limestone units. This is due to larger pore throats in dolomites and then the pores are connected together with larger pore throats.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

2017104113http://pr.ripi.ir/article_692_dc8215fb4a9325c1291bcb7bca2e1d9e.pdfdx.doi.org/10.22078/pr.2017.692Determination of mechanical and sedimentological properties of Asmari reservoir in one of the northwestern Dezful Embayment oilfieldssepidehsohrabiSchool of Geology, College of Science, University of Tehran, IranauthorSajjadGhareh-chelooSchool of Geology, College of Science, University of Tehran, IranauthorAliKadkhodaieDepartment of Geology, College of Science, University of Tabriz, IranauthorHossainRahimpour-BonabSchool of Geology, College of Science, University of Tehran, IranauthorGholam-HossainMontazeriPetroleum Engineering at Zagros Company, Shiraz, IranauthorSameddinEsmaeiliGeophysics at Iranian Central Oil Field Company, Tehran, Iranauthortextarticle2017perAsmari Formation is the most prolific and important hydrocarbon reservoir in south of Iran. This formation in the studied oilfield has mixed carbonate-siliciclastic lithology. Also, changes in its elastic modulus are correlatable with facies changes. To address these changes, we investigated the relation between sedimentary environment (facies) and texture with rock elastic properties (young’s modulus). Data from three wells are analyzed and used for the study of facies and young’s modulus. Based on elastic properties, facies and texture changes as well as petrophysical characteristics seven RMFs are recognized in the studied formation. To predict RMFs at any location in the field more efficiently, and capturing variations of the lateral formation properties as indicated by the post- stack seismic data, a 3D rock mechanical facies model is constructed. In this method, RMFs are correlatable between studied wells and map able by seismic attribute in the field scale. Finally, the distribution of RMFs and their related properties are recognized in the studied field.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

2017114128http://pr.ripi.ir/article_686_0fa0697abdf6c95b5317a8ec1b24e41c.pdfdx.doi.org/10.22078/pr.2017.686Optimization of Well Trajectory Using Particle Swarm Optimization Algorithm with Association of Proportional Feedbak Control-case StudyJavadKasraviPars Oil and Gas CompanyauthorMohammad AminSafarzadehTehran Energy Consultants CompanyauthorAyoubVali zadehPars Oil and Gas Companyauthortextarticle2017perOne of the important issues in the field of drilling engineering is the instability of oil and gas Wellbore. It is influenced by several factors; such as, azimuth, an inclination angle, in-situ stresses, mud weight, rock strength parameters, and etc. Among these factors, an azimuth angle, an inclination angle and mud weight are controllable. In this paper, a novel algorithm is introduced to obtain optimum Mud Pressure and finding the best well trajectory. Particle Swarm Optimization (PSO) was used as a main optimization engine; moreover, a strategy based on proportional (P) feedback control was applied to archive optimum condition. Normalized Yielded Zone (NYZA) Area was applied as an instability index and the feedback function uses the error between the simulated and set point Normalized Yielded Zone Area. A proposed algorithm is applied in one of directional well located in Ahwaz Oilfield. The results demonstrated that the optimum azimuth angle was near maximum horizontal stress (358.3°), and the optimum inclination angle was 67.4°. In addition, the minimum mud pressure for this trajectory was equal to 37.75 Mpa.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

2017129140http://pr.ripi.ir/article_702_5d9a08303073447868ca4e0c34ec8261.pdfdx.doi.org/10.22078/pr.2017.702Experimental Investigation and Modeling the Effect of CO2 and Rich Gas on the Kinetics of Asphaltene Precipitation from Live OilAhmad RezaZanganehChemical Engineering Department, Tarbiat Modares University(TMU), Tehran, IranauthorMohsenVafaie SeftiChemical Engineering Department, Tarbiat Modares University(TMU), Tehran, IranauthorMohammad MahdiShadmanChemical Engineering Department, Tarbiat Modares University(TMU), Tehran, IranauthorHasanNaderiReservoir Rock & Fluid Technology and Research Group, Research Institute of Petroleum Industry (RIPI), Tehran, Iranauthortextarticle2017perAsphaltene precipitation from reservoir fluids during oil production is a serious problem resulting in plugging of the formation, wellbore and production facilities. Generally, asphaltene precipitation has only been investigated from thermodynamic approach in literature, and it assumed that precipitation is relatively fast and has no kinetik effects. Without a good understanding of the associated kinetic effects during the precipitation of asphaltenes, the thermodynamic models can provide misleading predictions for asphaltene stability. So, it should be analyzed from two points of view, thermodynamic and kinetics stability. In this study a molar rich gas and CO2 programmed titration technique was used to evaluate the kinetics of gas-induced asphaltene precipitation from Iranian reservoir oil under isothermal and isobaric initial reservoir conditions in a solids detection system (SDS) and with kinetics of polymerization assumption for reaction between asphaltene and gas, the kinetics parameters of reaction is determined. The results show that asphaltene precipitation occurs in 0.9 mol of rich gas and 0.3 mol of CO2 injected per one mol of reservoir oil. Also, the reaction order of CO2 & rich gas is 2.7 times more than reaction order of asphaltene. So in gas injection, the rate of asphaltene precipitation is highly dependant to the volume of gas.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

2017141152http://pr.ripi.ir/article_696_a5c1bd7a00cf8cd8d0d77eebeac8e0f7.pdfdx.doi.org/10.22078/pr.2017.696Well Configuration Optimization Using Horizontal Wells in an Underground Gas-Condensate Storage ReservoirMohammad ImanRouhbakhsh ArfaeeInstitute of Petroleum Engineering (IPE), College of Chemical Engineering, University of Tehran, IranauthorBehnamSedaee SolaInstitute of Petroleum Engineering (IPE), College of Chemical Engineering, University of Tehran, IranauthorSiavashRiahiInstitute of Petroleum Engineering (IPE), College of Chemical Engineering, University of Tehran, Iranauthortextarticle2017perUnderground gas storage usually is used to assure stable supply during peak demand season of the year. With advances in gas storage at oil industry, optimization of storage reservoir performance and enhanced recovery is considered. In this paper, we focus on wells configuration optimization in an actual gas condensate reservoir. The injection/production well separation during underground gas storage leads to an increment in reservoir condensate recovery. The well separation reduces the number of wells that can be used either for injection or production. In addition to, the well separation reduces the produciblity of low permeability reservoirs, but because of high value of condensates and its minor effect on the produciblity of the reservoir with medium permeability, this approach is considered economical. The well configuration optimization and using horizontal wells in storage periods can increase the condensate recovery of the reservoir. Parameters which effect on well configuration optimization include: (1) water saturation, (2) injection/production well configuration and (3) reservoir permeability. As a production rate reaches to its specified value, and an optimized configuration in gas condensate reservoirs, production is maximized and the enhanced condensate recovery for remained fluid in the reservoir is achieved.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

2017153160http://pr.ripi.ir/article_689_d12c1766cd3a0e9e53893fe24b03d8f8.pdfdx.doi.org/10.22078/pr.2017.689Microfacies and Sedimentary Environments Investigation at the Ilam and Sarvak Formations Reservoir in Saadat-abad Oil FieldRezaSarmadiIranian Central Oil Fields Company, Tehran, IranauthorSeyed RezaMossavi HeramiDepartment of Geology, Ferdowsi University of Mashad, IranauthorAsadolahMahboubiDepartment of Geology, Ferdowsi University of Mashad, Iranauthortextarticle2017perIlam and Sarvak formations with middle cretaceous age are (belongs to Bangestan group) one of the very important oil and gas reservoirs in the Zagros basine .Ilam formation with carbonate facies is located between sarvak formation and gurpi formation. Based on importance, Sarvak formation has second place after Asmari reservoir. Four under-ground cross sections are selected from these formations in Saadatabad oil field wells No. (A, B, C, D) for investigating studies of sedimentary environments, sedimentary models and reservoir poroperties due to we did petrography and petrophysical studies on these formations .Based on microfacies studies and the results of orthochems, allochem and terigenous elements two sedimentary environments ((1) Shoal and (2) open marine environment) have been identified for ilam formation, and three sedimentary environments ((1) Lagoon, (2) Shoal, (3) Open marine) have been identified for Sarvak formations. Ilam formation included of two facies in Shoal environment and five facies in Open marine environment. Also, Sarvak formation has 16 facies in Lagoon, Shoal and Open marine environments , which indicates the production of the formations in a carbonat platform (a low slop carbonate ramp). The comparison between their facies and well logs (gamma ray, Sonic, Notron and Density) has shown that the their changing trends are coincident with together.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

2017161173http://pr.ripi.ir/article_694_0b554f5b41b62203e98bbb2148b2a494.pdfdx.doi.org/10.22078/pr.2017.694Investigation of New Hasan-Kabir’s Model and Effects of Friction Factor Correlations to Predict Pressure Drop in Vertical Oil WellsJavadJafaeiDepartment of Mechanical Engineering, Hakim Sabzevari University, IranauthorEsmailLakzianDepartment of Mechanical Engineering, Hakim Sabzevari University, Iranauthortextarticle2017perIn this study, a numerical modeling bespoke code has been used to identify the pressure drop and the flow pattern in three oil wells. The properties of the fluids are estimated by black oil PVT correlations. Conservation equations are formed for (1) mass, (2) momentum and (3) energy for each phase. For the first time, three oil wells are simulated with different two-phase models; such as, new Hasan and Kabir, old Hasan and Orkiszewski models. The new Hasan and Kabir model is selected due to good results. Determining friction is a very important factor to predict pressure drop and flow pattern in oil wells. Hasan and Kabir in their new simplified model used Chen correlation for friction factor. For determining the friction factor in rough pipes, the recently friction factor equation; such as, Colebrook equation, Goudar correlation, and Karagoz correlation are used and compared with each other. The effects of using the friction factor on the amounts of pressure drop is low. But in Qualitative study, Karagoz correlation, which is based on a new logarithmic velocity profile, shows better agreement with experimental data.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026

v.

5-95

no.

2017174183http://pr.ripi.ir/article_690_8e8859c062d407602cbfd6a47332a70e.pdfdx.doi.org/10.22078/pr.2017.690Reservoir Rock Type Identification Using Gustafson Kessel Algorithm and LOLIMOT EstimatorMehrnooshAlipour ShahsavariSchool of Mining Engineering, Faculty of Engineering, Tehran University, IranauthorHosseinMemarianSchool of Mining Engineering, Faculty of Engineering, Tehran University, IranauthorBehzadTokhmchiSchool of Mining Engineering, Faculty of Engineering, Tehran University, IranauthorSarehSadighSchool of Mining Engineering, Faculty of Engineering, Tehran University, Iranauthortextarticle2017perIdentifying reservoir rock types or a petrophysical rock type is separating a reservoir to homogeneous part based on petrophysical characterization like porosity and permeability. There are different ways to study the reservoir or petrophysical rock types like; Winland’s equation, Pittman’s equation and rock quality index. For detecting and separating reservoir zones based on these properties, we need core data but in most wells even if in all parts of one well, there is no way to coring. Nevertheless, logging will do in all wells. Because of that, finding some ways to estimate porosity and permeability using other available properties is very important. In this assay, for studying the efficiency of the local linear model tree (LOLIMOT) neuro-fuzzy system in detecting petrophysical rock types, we compare the achieved result with the core analysis and MLP neural network algorithm. Based on the results, the local linear model tree (LOLIMOT) neuro-fuzzy system has great sufficiency in reservoir zoning because this method uses a divided and conquer strategy. Besides, this for decreasing the efficiency of this method and studying the effect of homogenization of data on the result, the data were clustered with Gustafson Kessel clustering method before using the neuro-fuzzy system. According to the results, zoning petroleum reserviors will be done based on petrophsical rock type with higher accuracy. Finally, in this study, based on Winland’s equation and using well logs and core analyses, 2 wells in one of the reservoirs in south part of Iran were clustered, and thereby zoning and petrophysical rock types were well detected and separated from each other.
Journal of Petroleum Researchپژوهشگاه صنعت نفت2345-290026